scholarly journals Microbially Induced Calcium Carbonate Plugging for Enhanced Oil Recovery

Geofluids ◽  
2020 ◽  
Vol 2020 ◽  
pp. 1-10 ◽  
Author(s):  
Chenpeng Song ◽  
Derek Elsworth
Keyword(s):  
Calcium Carbonate ◽  
Oil Recovery ◽  
Extracellular Polymeric Substances ◽  
Pore Space ◽  
Pore Wall ◽  
Ion Source ◽  
Sweep Efficiency ◽  
Small Pore ◽  
Lower Permeability ◽  
Enhance Oil Recovery

Plugging high-permeability zones within oil reservoirs is a straightforward approach to enhance oil recovery by diverting waterflooding fluids through the lower-permeability oil-saturated zones and thereby increase hydrocarbon displacement by improvements in sweep efficiency. Sporosarcina pasteurii (ATCC 11859) is a nitrogen-circulating bacterium capable of precipitating calcium carbonate given a calcium ion source and urea. This microbially induced carbonate precipitation (MICP) is able to infill the pore spaces of the porous medium and thus can act as a potential microbial plugging agent for enhancing sweep efficiency. The following explores the microscopic characteristics of MICP-plugging and its effectiveness in permeability reduction. We fabricate artificial rock cores composed of Ottawa sand with three separate grain-size fractions which represent large (40/60 mesh sand), intermediate (60/80 mesh sand), and small (80/120 mesh sand) pore sizes. The results indicate a significant reduction in permeability after only short periods of MICP treatment. Specifically, after eight cycles of microbial treatment (about four days), the permeability for the artificial cores representing large, intermediate, and small pore size maximally drop to 47%, 32%, and 16% of individual initial permeabilities. X-ray diffraction (XRD) indicates that most of the generated calcium carbonate crystals occur as vaterite with only a small amount of calcite. Imaging by SEM indicates that the pore wall is coated by a calcium carbonate film with crystals of vaterite and calcite scattered on the pore wall and acting to effectively plug the pore space. The distribution pattern and morphology of microbially mediated CaCO3 indicate that MICP has a higher efficiency in plugging pores compared with extracellular polymeric substances (EPSs) which are currently the primary microbial plugging agent used to enhance sweep efficiency.

scholarly journals Microbially induced calcium carbonate precipitation driven by ureolysis to enhance oil recovery

RSC Advances ◽  
2017 ◽  
Vol 7 (59) ◽  
pp. 37382-37391 ◽  
Author(s):  
Jun Wu ◽  
Xian-Bin Wang ◽  
Hou-Feng Wang ◽  
Raymond J. Zeng
Keyword(s):  
Calcium Carbonate ◽  
Oil Recovery ◽  
Carbonate Precipitation ◽  
Calcium Carbonate Precipitation ◽  
Sweep Efficiency ◽  
Enhance Oil Recovery

Microbially induced calcium carbonate precipitation was used to improve poor volumetric sweep efficiency of water and enhance oil recovery.

scholarly journals Investigation on the effect of active-polymers with different functional groups for EOR

e-Polymers ◽  
2020 ◽  
Vol 20 (1) ◽  
pp. 61-68
Author(s):  
Dong Zhang ◽  
Jian Guang Wei ◽  
Run Nan Zhou
Keyword(s):  
Functional Groups ◽  
Oil Recovery ◽  
Molecular Size ◽  
Type I ◽  
Cleaning Efficiency ◽  
Sweep Efficiency ◽  
Profile Control ◽  
Branched Chain ◽  
Swept Volume ◽  
Enhance Oil Recovery

AbstractActive-polymer attracted increasing interest as an enhancing oil recovery technology in oilfield development owing to the characteristics of polymer and surfactant. Different types of active functional groups, which grafted on the polymer branched chain, have different effects on the oil displacement performance of the active-polymers. In this article, the determination of molecular size and viscosity of active-polymers were characterized by Scatterer and Rheometer to detect the expanded swept volume ability. And the Leica microscope was used to evaluate the emulsifying property of the active-polymers, which confirmed the oil sweep efficiency. Results show that the Type I active-polymer have a greater molecular size and stronger viscosity, which is a profile control system for expanding the swept volume. The emulsification performance of Type III active-polymer is more stable, which is suitable for improving the oil cleaning efficiency. The results obtained in this paper reveal the application prospect of the active-polymer to enhance oil recovery in the development of oilfields.

Improving CO2 storage and oil recovery by injecting alcohol-treated CO2

2020 ◽  
Vol 60 (2) ◽  
pp. 662
Author(s):  
Saira ◽  
Furqan Le-Hussain
Keyword(s):  
Oil Recovery ◽  
Co2 Sequestration ◽  
Computer Modelling ◽  
Co2 Storage ◽  
Co2 Injection ◽  
Displacement Efficiency ◽  
Sweep Efficiency ◽  
Numerical Studies ◽  
Reservoir Simulator ◽  
Enhance Oil Recovery

Oil recovery and CO2 storage related to CO2 enhance oil recovery are dependent on CO2 miscibility. In case of a depleted oil reservoir, reservoir pressure is not sufficient to achieve miscible or near-miscible condition. This extended abstract presents numerical studies to delineate the effect of alcohol-treated CO2 injection on enhancing miscibility, CO2 storage and oil recovery at immiscible and near-miscible conditions. A compositional reservoir simulator from Computer Modelling Group Ltd. was used to examine the effect of alcohol-treated CO2 on the recovery mechanism. A SPE-5 3D model was used to simulate oil recovery and CO2 storage at field scale for two sets of fluid pairs: (1) pure CO2 and decane and (2) alcohol-treated CO2 and decane. Alcohol-treated CO2 consisted of a mixture of 4 wt% of ethanol and 96 wt% of CO2. All simulations were run at constant temperature (70°C), whereas pressures were determined using a pressure-volume-temperature simulator for immiscible (1400 psi) and near-miscible (1780 psi) conditions. Simulation results reveal that alcohol-treated CO2 injection is found superior to pure CO2 injection in oil recovery (5–9%) and CO2 storage efficiency (4–6%). It shows that alcohol-treated CO2 improves CO2 sweep efficiency. However, improvement in sweep efficiency with alcohol-treated CO2 is more pronounced at higher pressures, whereas improvement in displacement efficiency is more pronounced at lower pressures. The proposed methodology has potential to enhance the feasibility of CO2 sequestration in depleted oil reservoirs and improve both displacement and sweep efficiency of CO2.

scholarly journals High-viscosity α-starch nanogel particles to enhance oil recovery

RSC Advances ◽  
2020 ◽  
Vol 10 (14) ◽  
pp. 8275-8285 ◽  
Author(s):  
Tuo Liang ◽  
Jirui Hou ◽  
Ming Qu ◽  
Mengdan Zhao ◽  
Infant Raj
Keyword(s):  
Oil Recovery ◽  
Water Channels ◽  
High Viscosity ◽  
Sweep Efficiency ◽  
Enhance Oil Recovery

The formation of dominant water channels is a serious problem for most oilfields, which results in low sweep efficiency.

Laboratory Development of Lignosulfonate Gels for Sweep Improvement

1977 ◽  
Vol 17 (06) ◽  
pp. 391-397 ◽  
Author(s):  
Betty J. Felber ◽  
Dwight L. Dauben
Keyword(s):  
Oil Recovery ◽  
High Capacity ◽  
High Water ◽  
Silica Gels ◽  
Systematic Evaluation ◽  
Sweep Efficiency ◽  
Sodium Dichromate ◽  
Low Viscosity ◽  
Lower Permeability ◽  
Pass Through

Abstract The development of a lignosulfonate gel system for improving sweep efficiency is discussed. The gel mixture is injected as a low-viscosity fluid into a loose streak. After gelation occurs, subsequently injected fluids are diverted into lower-permeability intervals. The developed system is composed of 95 percent or More water, ammonium lignosulfonate, and a mixed activator of sodium dichromate and salt. Laboratory studies show that lignosulfonate gels exhibit the following properties:long gel times can be designed, e.g., gel times up to 2 1/2 months were obtained at 190 degrees F;gel strength can be controlled to produce the level of flow reductions required for a particular application. Controlled flow reduction, rather than complete flow blockage, is needed where the loose streak may contain appreciable amounts of oil recoverable by further waterflooding or by a miscible flood;available injection waters, even highly saline ones, can be used for mixing the gel solutions; andlignosulfonates, with no activator, gel when exposed to temperatures in the range of 300 to 450 degrees F. A fluid with these properties should be useful in controlling sweep in high-temperature reservoirs or steamfloods. Introduction Reservoir heterogeneities, such as loose streaks or fractures, may limit oil recovery in waterflood operations. The injected water may break through prematurely and producing wells abandoned because prematurely and producing wells abandoned because of high water cuts, even though much of the oil in the reservoir is left behind. In spite of sweep problems, many waterfloods have been successful problems, many waterfloods have been successful because water is inexpensive and can be cycled to displace oil gradually from the matrix or lower permeability regions. permeability regions. Recent papers have pointed out that good volumetric sweep efficiency is particularly important in miscible recovery operations. An expensive slug of gas solvent or micellar fluid recovers only the oil that is contacted on a single pass through the reservoir. Thus, it is important that the miscible fluid contact a significant portion of the reservoir. One suggested method for improving sweep to micellar fluid involves prepolymer injection. Because of the growing awareness of the importance of good sweep, greater emphasis is being placed on the diagnosis of reservoir heterogeneities and development of materials for correcting diverse sweep problems. Polymers in various forms have been proposed for improving volumetric sweep caused by a poor mobility ratio or by permeability contrasts. Gels are used for the more severe channeling problems caused by loose streaks. Solid fines and gels are used for fracture plugging. plugging. A previous paper discussed the development and application of alkaline silica gels for selective plugging. Silica gels have been and will continue plugging. Silica gels have been and will continue to be used where the need is to eliminate flow through high-capacity loose streaks. However, with continued application, it has become apparent the silica gels do have some limitations. These includeshort gel times at high temperatures (e.g., about 10 hours at 200 degrees F) that limit the volume of gel mixture that can be injected, andsensitivity to salts that necessitates the use of fresh water for mixing and preflushing and that causes premature gelation in formations containing soluble compounds (e.g, gypsum or anhydrite). This paper describes the development of lignosulfonate gels for improvement of sweep. These gels overcome some of the above limitations of silica gels and also offer additional advantages. DESCRIPTION OF THE SYSTEM This selected system is composed of 95 percent or more water, a lignosulfonate, and a mixed activator of sodium dichromate and salt. This system has evolved from a systematic evaluation of the known reaction of a lignosulfonate with dichromate. SPEJ P. 391

scholarly journals Macroscopic Profile Modification and Microscopic Displacement Mechanism of Weak Gel Flowing in Porous Media

2016 ◽  
Vol 2016 ◽  
pp. 1-7 ◽  
Author(s):  
Jian Wang ◽  
Bo Kang ◽  
Liehui Zhang ◽  
Beata Joanna Darowska ◽  
Peng Xu
Keyword(s):  
Porous Media ◽  
Oil Recovery ◽  
Positive Influence ◽  
Water Flooding ◽  
Sweep Efficiency ◽  
Microscopic Scale ◽  
Profile Modification ◽  
Small Pore ◽  
Weak Gel ◽  
And Function

In this paper, the flowing mechanism and function on the macroscopic and microscopic scale in the porous media of a widely used weak gel of an acrylamide based polymer crosslinked with chromium(III) were studied. Innovative microscopic plane visualization model was designed for microscopic scale experiment and sand pack physical model for macroscopic scale. The microscopic displacing experiments indicate that weak gel mainly intrudes into big pores rather than small ones, which can improve the conformance horizontally and increase the sweep efficiency benefiting from fluid diversion. Additionally, due to good viscoelasticity of weak gel, the negative pressure effect was formed enhancing oil recovery flow from small pore throats. Results of macroscopic physical sand pack flow experiment indicate positive influence of weak gel on vertical conformance control. Although the high permeable layer was not completely blocked, the oil recovery improved as a result of weak gel movement by continuous water flooding. Experiments results lead to conclusion, the primary function of weak gel is oil displacement, profile modification is secondary, and its effect is temporary.

A Microvisual Study of the Displacement of Viscous Oil by Polymer Solutions

2011 ◽  
Vol 14 (03) ◽  
pp. 269-280 ◽  
Author(s):  
M.. Buchgraber ◽  
T.. Clemens ◽  
L. M. Castanier ◽  
A. R. Kovscek
Keyword(s):  
Polymer Solution ◽  
Oil Recovery ◽  
Polymer Solutions ◽  
Pore Space ◽  
Polymer Concentration ◽  
Water Injection ◽  
Sweep Efficiency ◽  
Improved Oil Recovery ◽  
Associative Polymers ◽  
Displacement Front

Summary Of the various enhanced-oil-recovery (EOR) polymer formulations, newly developed associative polymers show special promise. We investigate pore and pore-network scales because polymer solutions ultimately flow through the pore space of rock to displace oil. We conduct and monitor optically water/oil and polymer-solution/oil displacements in a 2D etched-silicon micromodel. The micromodel has the geometrical and topological characteristics of sandstone. Conventional hydrolyzed-polyacrylamide solutions and newly developed associative-polymer solutions with concentrations ranging from 500 to 2,500 ppm were tested. The crude oil had a viscosity of 450 cp at test conditions. Our results provide new insight regarding the ability of polymer to stabilize multiphase flow. At zero and low polymer concentrations, relatively long and wide fingers of injectant developed, leading to early water break-through and low recoveries. At increased polymer concentration, a much greater number of relatively fine fingers formed. The width-to-length ratio of these fingers was quite small, and the absolute length of fingers decreased. At a larger scale of observation, the displacement front appears to be stabilized; hence, recovery efficiency improved remarkably. Above a concentration of 1,500 ppm, plugging of the micromodel by polymer and lower oil recovery was observed for both polymer types. For tertiary polymer injection that begins at breakthrough of water, the severe fingers resulting from water injection are modified significantly. Fingers become wider and grow in the direction normal to flow as polymer solution replaces water. Apparently, improved sweep efficiency of viscous oils is possible (at this scale of investigation) even after waterflooding. The associative- and conventional-polymer solutions improved oil recovery by approximately the same amount. The associative polymers, however, showed more-stable displacement fronts in comparison to conventional-polymer solutions.

Polymer Gelled Technology to Improve Sweep Efficiency in Enhanced Oil Recovery: A Literature Review

2015 ◽  
Vol 1113 ◽  
pp. 690-694 ◽  
Author(s):  
Norfarisha Achim ◽  
Nur Hashimah Alias ◽  
Nurul Aimi Ghazali ◽  
Miradatul Najwa Muhd Rodhi ◽  
Tengku Amran Tengku Mohd ◽  
...  
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Polymer Gels ◽  
Fluid Injection ◽  
Potential Candidate ◽  
Polymer Gel ◽  
Excellent Performance ◽  
Sweep Efficiency ◽  
Enhance Oil Recovery ◽  
Permeability Modification

This article is an overview of the use of polymer gelled technology to improve sweep efficiency in enhanced oil recovery. Recent progress use polymer types, Polyacrylamide and polysaccharide to be applied in enhanced oil recovery (EOR). A lot of researchers concluded that polymer gel stability must be maintained to ensure excellent performance in sweep efficiency. The application of polymer gels in permeability modification to improve volumetric sweep efficiency of fluid injection processes showed fruitful efforts as it can be a potential candidate to enhance oil recovery as compared to other technologies.

Cellulose Nanocrystal Switchable Gel Improves CO2 Sweep Efficiency

2021 ◽  
Vol 73 (11) ◽  
pp. 58-59
Author(s):  
Chris Carpenter
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Average Length ◽  
Technical Conference ◽  
Cellulose Nanocrystal ◽  
Sweep Efficiency ◽  
Flowing Liquid ◽  
University Of Calgary ◽  
Lower Permeability ◽  
Carbon Dioxide Co2

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 201609, “Cellulose Nanocrystal Switchable Gel for Improving CO2 Sweep Efficiency in Enhanced Oil Recovery and Gas Storage,” by Ali Telmadarreie, University of Calgary and Cnergreen; Christopher Johnsen, University of Calgary; and Steven Bryant, University of Calgary and Cnergreen, prepared for the 2020 SPE Annual Technical Conference and Exhibition, originally scheduled to be held in Denver, 5–7 October. The paper has not been peer reviewed. The entanglement of biopolymers is a well-known phenomenon that, when controlled, can result in a smart fluid with strong gelation properties. The authors write that, when a suitable salt is incorporated into the cellulose nanocrystal (CNC), the fluids undergo gelation upon contact with bulk-phase carbon dioxide (CO2) but remain a flowing liquid otherwise. In this study, this composition-selective trigger was applied to improve sweep efficiency in CO2 enhanced oil recovery (EOR) and sequestration. Introduction Hydrogels are hydrophilic structures that swell when hydrated and have various applications in industry. Hydrogels are of interest in EOR because of their ability to respond to stimuli such as pH, temperature, light, and ionic strength. CNCs are nanoparticles derived from cellulose, one of the more sustainable natural resources available. CNC hydrogels could have specific applications as a solution to media het-erogeneity and poor gas-sweep efficiency. The hydrogels can be tuned to set over time, allowing the intentional placement of gels into already-swept areas of a reservoir. CNC hydrogels are unique in that they can be formed when contacted with CO2 and broken by the application of nitrogen (N2) gas. The pH of the solution will be increased as the nitrogen partitions across the gel, reversing the CO2 reaction. This gives the gel-forming solution the added benefit of being transmittable throughout a reservoir. Material and Procedure Spray-dried CNCs with an average length of 100–200 nm and a width of 15 nm were used. Imidazole was used as the salt mixed with water and CNC suspension to create a pH-triggered gel system. CO2 gas and N2 gas were used as received. Mineral oil with a viscosity of approximately 20 cp was used at the oil phase. Solution preparation, and the process for gel strength in bulk testing, are provided in the complete paper. All tests were performed at a pressure of 400 psi and an ambient temperature of 21°C. Two sets of flow experiments were performed. The first included flow in a single sandpack saturated with water to investigate the in-situ gelation and reversibility of the gel. The second set used a dual-sandpack system. The shorter sandpack with higher permeability was saturated with water to create a path of less resistance compared with the longer sandpack with lower permeability saturated with viscous oil. Further details of these experiments are provided in the complete paper.

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